The URL can be used to link to this page

Home My WebLink About197-047 • S RECEIVEPost Office Box 244027 JUL3 0 4 Anchorage,AK 99524-4027 Hilcorp Alaska,LLC U201` 3800 Centerpoint Drive Suite 100 ^C Anchorage,AK 99503 /6.�e1: Phone: 907/777-8300 July 29, 2015 Fax: 907/777.-8301 Commissioner Cathy Foerster SGOS( Alaska Oil & Gas Conservation Commission / r 333 West 7th Avenue, Suite 100 l 0 47 Anchorage, AK 99501 1 L( Re: Duck Island Unit Well Renaming Request Dear Commissioner Foerster, Hilcorp Alaska, LLC (HAK) requests a change to the naming convention of Duck Island Unit wells to remove the unused suffixes at the end of each well name. Well names currently include a forward slash "/" followed by an obsolete bottom hole location designator. HAK would like to retain the well number as well as the "A, B, C...." sidetrack designations but remove the "/suffix". For example, "DUCK IS UNIT SDI 1-09A/L21" would become "DUCK IS UNIT SDI 1-09A". The attached spreadsheet includes original and new names for all Duck Island wells. While performing the review of Duck Island well names, HAK found a single well, "DUCK IS UNIT SDI 4-20/M35" (PTD# 1861730), that should also be modified to include an "A" label to reflect the fact that the well is a sidetrack from the original "DUCK IS UNIT SDI 4-20/T34" (PTD # 1861500). The original wellbore, abandoned 10/13/1986, was sidetracked to a new bottom hole location completed on 9/9/1987. This well appears to be one of the first sidetracks performed at Endicott. While the bottom hole code was changed, no letter was added to reflect the sidetrack. "DUCK IS UNIT SDI 4-20A" is also included on the attached spreadsheet. Sincerely, Wyatt Rivard Well Integrity Engineer Hilcorp Alaska, LLC CC Dave Roby Victoria Loepp • Orig • New API_WeliNo PermitNumber WeliName WellNumber I I WeilNumber 50029219460600 2032160 DUCK IS UNIT SDI 3-17F/K30 3-17F 50029224630000 1940490 DUCK IS UNIT SDI 3-19/R28 3-19 50029217140000 1870330 DUCK IS UNIT SDI 3-21/L34 3-21 50029217149500 1980190 DUCK IS UNIT SDI 3-21AK35XX 3-21AXX 50029216450000 1861550 DUCK IS UNIT SDI 3-23/N32 3-23 50029221250000 1901820 DUCK IS UNIT SDI 3-25/M27 3-25 50029221250100 2010200 DUCK IS UNIT SDI 3-25A/N24 3-25A 50029221250200 2030210 DUCK IS UNIT SDI 3-25B/L27 3-25B 50029215860000 1860830 DUCK IS UNIT SDI 3-27/M33 3-27 50029221060000 1901560 DUCK IS UNIT SDI 3-29/J32 3-29 50029228380000 1972270 DUCK IS UNIT SDI 3-31/K32 3-31 50029216680000 1861800 DUCK IS UNIT SDI 3-33/K37 3-33 50029216680100 2032150 DUCK IS UNIT SDI 3-33A/J35 3-33A 50029217010000 1870200 DUCK IS UNIT SDI 3-35/L36 3-35 50029225540000 1950510 DUCK IS UNIT SDI 3-37/L35 3-37 50029217640000 1871160 DUCK IS UNIT SDI 3-39/J39 3-39 50029217640100 1970910 DUCK IS UNIT SDI 3-39A/137 3-39A 50029218780000 1881260 DUCK IS UNIT SDI 3-41/K39 3-41 50029224160000 1931700 DUCK IS UNIT SDI 3-43/P36 3-43 50029218110000 1880510 DUCK IS UNIT SDI 3-45/M39 3-45 50029215690000 1860640 DUCK IS UNIT SDI 3-47/Q35 3-47 50029217350000 1870600 DUCK IS UNIT SDI 3-49/J40 3-49 50029217350200 1970570 DUCK IS UNIT SDI 3-49A/M40 3-49A 50029217359500 1950350 DUCK IS UNIT SDI 3-49AJ40XX 3-49AXX 50029217890000 1880220 DUCK IS UNIT SDI 4-02/Q28 4-02 50029219680000 1890860 DUCK IS UNIT SDI 4-04/T26 4-04 50029219680100 2090190 DUCK IS UNIT SDI 4-04A/T30 4-04A 50029217230000 1870430 DUCK IS UNIT SDI 4-06/Q32 4-06 50029217230100 1961660 DUCK IS UNIT SDI 4-06A/Q30 4-06A 50029216920000 1870080 DUCK IS UNIT SDI 4-08/P27 4-08 50029224640000 1940500 DUCK IS UNIT SDI 4-10/M28 4-10 50029224640100 2022380 DUCK IS UNIT SDI 4-10A/L28 4-10A 50029218630000 1881040 DUCK IS UNIT SDI 4-14/R34 4-14 50029218630100 2080120 DUCK IS UNIT SDI 4-14A/S-37 4-14A 50029218960000 1881490 DUCK IS UNIT SDI 4-18/S30 4-18 50029216400100 1861730 DUCK IS UNIT SDI 4-20/1V135 4-20A 50029216400000 1861500 DUCK IS UNIT SDI 4-20/T34 4-20 50029218350000 1880720 DUCK IS UNIT SDI 4-26/034 4-26 50029218700000 1881110 DUCK IS UNIT SDI 4-28/N37 4-28 50029225590000 1950690 DUCK IS UNIT SDI 4-32/K38 4-32 50029227050000 1961550 DUCK IS UNIT SDI 4-34/038 4-34 50029224820000 1940740 DUCK IS UNIT SDI 4-38/K34 4-38 50029222650000 1920420 DUCK IS UNIT SDI 4-40/P43 4-40 50029217310000 1870560 DUCK IS UNIT SDI 4-42/P38 4-42 50029222540000 1920190 DUCK IS UNIT SDI 4-44/M44 4-44 50029222549500 1970470 DUCK IS UNIT SDI 4-44AM40XX 4-44AXX 50029219570000 1890690 DUCK IS UNIT SDI 4-46/N39 4-46 50029219720000 1890970 DUCK IS UNIT SDI 4-48/K43 4-48 50029219400000 1890440 DUCK IS UNIT SDI 4-50/K41 4-50 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. j~ '~-~ ¢ ~ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. ,[3 Maps: Grayscale items: [] Poor Quality Originals: [] Other: [] Other, No/Type [] Other items scannable by large scanner OVERSIZED (Non-Scannable) o Logs of various kinds TOTAL PAGES: NOTES: ORGANIZED BY~ BEVERLY BREN SHERYL MARIA LOWELl. [] Other ISl ~. By: Date: ;-. PAGES:~(~~''- (at the time of scanning) SCANNED BY; BEVERLY BREN~~HERYL' MARIA LOWELL DATE: ReScanned (done) RESCANNEDBY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl General Notes or Comments about this file: Quality Checked (done) Rev1NOTScann~cl.v4~l ~KA OIL AND GAS CONSERVATION CO~SSION TONY KNOWLES, GOVERNOR 333 W, 7T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Fritz Gunkel, Manager Drilling BP Exploration (Alaska) Inc. PO Box 196612 Anchorage AK 99519 Re: Cancelled or Expired PTD's. Dear Gunkel: September 6, 2001 The Alaska Oil and Gas Conservation Commission ("AOGCC") approved the following referenced permit to drills. The AOGCC has a long-standing policy of releasing cancelled or expired permits two years from the date the application was approved by the AOGCC. The following files are scheduled to be released October 1, 2001. Permit to Drill No.'s: 97-047 98-019 99-002 97-056 98-050 99-009 97-082 98-135 ,, 97-090 98-154 97-100 98-155 97-121 98-164 97-159 98-167 97-191 98-177 98-210 98-211 98-223 98-236 98-257 98-261 Sincerely, Memorandum State of Alaska Oil and Gas Conservation Co~ To: Well File: C~ f~ -. ~~ DATE Re: Cancelled or Expired Permit Action EXAMPLE: Point McIntyre P2-36AXX API# 029-22801-95 31, tqq This memo will remain at the front of the subject well file. Our adopted conventions for assigning AP! numbers, permit numbers and well names did not specifically address expireci or cancelled permits. This omission has caused some inconsistencies i· the treatment of these kinds of applications for permit to ddii. Operators have asked us to adopt formal procedures for this class of permit application in order to prevent future database disparities. If a permit expires or is cancelled by an operator, the permit number of the subject permit will remair, unchanged. The APl number and in some instances the well name reflect the number of preexistin,( reddils and or muitilaterals in a well. In order to prevent confusing a cancelled or expired permit with an active well or multilateral these case sensitive well identifiers will be changed for expired and cancelled applications for permits to ddll. The AP! number for this cancelled or expired permit is modified so the eleven and twelfth digits is 9[ 'he well name for a cancelled or expired permit is modified with an appended xx. ~,se procedures are an addenclum to the AP! numbering methods descnbed in AOGCC staff qorandum "Multi-lateral (wetibore segment) Drilling Permit Procedures, revised December 29, · 'C database has been changed to reflect these changes to this permit. 'echnician BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 To: From: Date: Subject: Blair Wondzell, AOGCC Chris West, BPX (Shared Services Drilling) April 8, 1997 Clarification letter for Endicott/M-40 Permits As part of our current drilling program at Endicott, we had planned to sidetrack to the M-40 bottom hole location from the closest well, which was the 4-44/M-40. The Sundry and Permit to Drill applications have been approved. During the abandonment of the existing completion, the coil tubing became stuck so we planned a contingency to sidetrack from the next closest well which was theT4-48/K-43 well. The Sundry for well 4-48 has also been approved. However, we were asked to evaluate other options from which to sidetrack to the M-40 location which yielded 3-49/J- 40 as the next best candidate for this operation. Both the Sundry and Permit to Drill application for 3-49 have been approved. As diScussed, we have started this sidetrack operation and no longer need the' other two Permit to Drill Applications for 4-44 and the 4-48/we11. We may consider these as sidetrack candidates at some future dates, but would submit new Permit to Drill applications at that time. Your assistance in obtaining these permits is greatly appreciated, and is a witness to the working relationship we have developed. Thank you for your assistance in this matter. Please direct any further questions to Chris West at 564-5089. Respectfully, Chris West cc: BPX M-40 Wellfile R 1 I 1997 .& 6as Cons. C0m, I~,!~,' Anchorage TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 March 27, 1997 Steve Shuitz Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Duck Island Unit 4-44A/M-40 BP Exploration (Alaska) Inc. Permit No: 97-47 Sur. Loc.: 2609'NS[,. 618'WEL, Sec. 8, TllN, R17E, UM Btmhole Loc: 2517'NSL, 4968'WEL, Sec. 10, T11N, R17E, UM Dear Mr. Shultz: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximate(,,. 24 hours) of the BOPE test performed before drilling below the surface casing shoe lnUSt be given so that a representative of the Commission may' witness the test. Notice may be given bv contacting the Commission petroleum field inspector on the North Slope pager at 65%3607. Sincerely, , Mary Marshburn Commissioner BY ORDER OF THE COMMISSION dltTenclosures cc: Department of Fish & Game. Habitat Section w/o encl. Department of Envinornment Conservation w/o enct. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL ,.vi..d: o~n4/s7 20 AAC 25,005 la. Type of work [] D?i[] [] Redrill It b. Type of we]l E]'~'~)-I'oratory -¢'istr~'tlgraphlc Test [] D~(,~lopment Oil r'~Re-_E._n_t_ry I-IDeepenI E] Service. .f l..Development Gas I-ISingle Zone I-'lM.u..ItJple Zone 2. Name of Operator 5. Datum Elevation (DF or KB-)- 10. Field and Pool BP Exploration (Alaska,! Inc. Plan RTE = 56' Endlcoff Field / Endicott Pool 3. Address '- 6. 'Propane"Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 047503 4. Locatio~o;~ ~il-~'s~rface .......... 7. Unit or Property N~.~ ....... 11. Type Bond (See 20 AAC 25.025) 2609' NSL, 618' WEL, SEC. 8, T11N, R17E Duck Island At top of productive interval ~. Well Number ..... Number 2S 100302630-277 2167' NSL, 45' WEL, SEC. 9, TllN, R17E 4-44NM-40 At total depth 9. Approximate spud date Amount $200,000.00 2517' NSL, 4968' WEL, SEC. 10, TllN, R17E 04/01/97 12. Distance to near~sl'l~'r~'perty line113. Distance to nearest well 14: 'l~'~J-m-~er of acres in property 15. Proposed ~e;l~{h (MD and TvO) ADL047505, 2517' ,,..I 4-40/P-43, 1265'e! 10609' MD 2560 13522' MD / 10456' TV[:) 16. To be completed for deviated wells 17. Antici~.~t'ed pressure [~oe ~o~,~c ~.03~ Kick Off Depth 10,000' Max.~.m_u ,m Hole An,qle 5a,7~ ~ M~xJmum sudace 3950 psig, At telal depth ('I'VD) 10000' / 4950 p$ig 18. Casing Program Specifications ....... Setting'D~'pth Size Top Bottom ........ Quantity of Cement ,,. Hole " 'Casing Weigh. t_ G~;de- Coupling Lengtl~" MD TVD MD TVD (include stage data) .."8-1/2" 7" 29# L-80 . !B.~ 3659' 9150' ~600' 13316' .1.?_~_5___6.' 300 SX Class 'G;' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) . ~.. .~, true ve~lical feet . Onsing Le.gth Size Cemented ~~,, ~1~-~[~~:~ ..... TVD Structural Conductor ,,:.~ m~ ~i,~ , LPirn°elucti°n0 RIG INA L Perforation depth: measured true vertical 20. Attacl~nents M _Filing Fee [] Propert7 Plat [] BOP Sk;-'{~'" [] Diverter Sketch [] Drllllng P'm'~Car~ -- ~tl Ddll[ng Fluid Program rlTirne ye Depth Plot [] Refraction Analysis f'l Seabed Report [] ;~0 AAO 2~.0§0 Requirements , ,..,. ,,., ,,,., 'Contact Engineer Name/Number: Chris West, $64-5089 Prepared By Name/Number: Kathy carnpoamor, 584-5122 21. I hereby certify tl~t'ihe foregoing is true'and correct to the' ~est of my knowledge Signed e~.Sh~. ......... Tit[e Senior,.B, dlling Engineer D~t_e_. Commission Use Only I' I ' ....... Permit Nun~ber ....~ ] ~F~l i~u~ber ' ] -~i~rov~ll ~) ~ate - ~11 I ~ee cover letter Conditions of Approval: Samples Required O Yes 1~ No Mud Log Required ~ Yes [] No Hydrogen Sulfide Measures I~Yes O No Directional Survey Required [] Yes [] No Required Working Pressure for BOPE [] 2M; O 3M; ~ SM; [] 10M; [] 15M Olher: by order of Approved By Comm[,s.si. oner the commission Date Form 10-401 Rev, 12-01-85 ;~/;? ' d Submit In Tripiicate OHI99I~C[ S33I^~3S (Z3NIdHS NU/..~:'~'[ 2.6, P~; ~iUN EV = 54' /' ~' "13 3/8" 68#/ft · N~'~0C~'H E, ' "' BTRS. CSG. _ _ .. w · cement Plug Top of Cement 500" MDabove Kekiktuk *Hazard Warning: From the Top of the Kekiktuk to the top of the 3A there is the possibility of variable reservoir pressure( 5.5 - 10.1 ppg emw). Projected Tops & Contacts MDRKB TVDSS GOC NA Top Kek 9950' Top Fiii 10000' Top Fii 10055' Top Fi 10170' OWC 10200' Top 3A 10251' DATE REV. BY COMMENTS TREE: 4-3/8" / 5000 psi McEVOY/OTIS (SSV) WELLHEAD: 13-5/8' / 5000 psi / FMC SSSV LANDING NIPPLE (3.813"-MIN. ID)_ I !600' W/SSSV MIN I.D. is 2.0" 7' / 9-5/8" Liner Top Packer ~ 9-5/8", 47#/ft, .... NTO5HS, NSCC 4-1/2" 12.6#/ft L-80 Tbg I.D. = 3.958" Drift thru string = 3.833" ~ IIFT MANnRFI R NO MD-BKB TVD-RR #6 3500' #5 5250' #4 6300' #3 7000' #2 T/00' 4-1/2" 'X' NIPPLE (3.813" ID) .. ProductionPacker 4-1/2" 12#/ft L-80 Tailpipe 4-1/2" 'X' NIPPLE I (3.813" ID) I 4-1/2" 'XN' NIPPLE (3.725" I'D) I WLEG I Set the tubing string so that the WLEG is approximately 350' MD above the Top of the Kekiktuk (facilitates CTU squeezing & logs). A two nipple 100' tailpipe assembly is recommended. The packer setting depth (450t MD above the Top of the Kekiktuk) should be below the top of the cement (500' MD above the top of the Kekiktuk). PBTD (top of float collar & cement) should be at least 100' below the OWC (10200' TVDSS). .~.__ 7" Prod Csg ENDICOTT WELL 4-44A / M'40 APl NO: 50-029- PROPOSED DRILLING DIAGRAM BP EXPLORATION, INC. I Well Name: 14-44a/M-40 Well Plan Summary I Type of Well (producer or injector): IPr°ducer I Surface Location' 2609 FSL 618 FEL S08 T11N R17E UM Tie in survey Location: 2071 FSL 361 FEL S09 T11N R17E UM Target I Location- 45 FSL 2167 FEL S09 T11N R17E UM Bottom' Hole Location: 2517 FSL 4968 FEL S10 T11N R17E UM I AFE Number:IT27009 I IEstimated Start Date: 411197 I Rig' I DOYON 15 Operating days to drill 120+5 and complete: I I'MD' 113,288 I ITvD: 110,380 IIKBE' 156 J Well Design (conventional, slimhole, etc.)' Formation Markers Well Bore: I SIDETRACK Formation Tops M D TVD SS RESERVOIR PRESSURE TOP WEST SAK TOP SEABEE/AYLYAK KOP 10,000 MD / 7,168 TVDSS TOP SHALE 11915 9230 WALL/TUFFS TOP HRZ 12354 9664 BASE HRZ 12655 9918 TOP PUT RIVER 9918 BASE PUT RIVER (LCU) 9950 LCU 9950 KEKIKTUK - Top Flow 5 AB Top Flow4 12699 Trunc Top Flow 3 12767 10,000 4400 - 4950 psi @ 10,000 TVDSS Top Flow 2 12843 10,055 2500 - 4500 psi @ 10,055 TVDSS Top Flow 1 13002 10,170 4850 psi @ 10,170 TVDSS Top Zone 3A3(P3) 13112 10,251 4600 - 4800 psi @ 10,251 TVDSS TD 13288 10,380 Logging Program: Logs: 8.5" Hole Tan~lent and Curve Wireline Logs - TD to HRZ Cased Hole: MWD Only DIL/LDT/CNL/GR, RFT Based on OH Logs None Casin ;I/'l'ubinq Program: Hole Csg! Wt/Ft Grade Conn Length Top Btm Size Tbg MD/TVD MD/TVD O.D. 8.5 7" 29 L-80 IBM 4138 9150/6600 13288/10380 TBG 4.5" 12.6 L-80 NSCT 12,462 38 12500/9826 4-44a/M-40a Drilling Permit 3/10/97 Cementinq Prog ran : ~1~ v Hole Section Liner Size Depth Volume Cement Production 7" Liner from Cement _ 300 Class 'G' 9,850 to 13,439 from Sxs 0.5% CFR 2 with 11,849 0.7% Halad 344 7" x 9-5/8" liner to 0.1% HR-5 hanger 13,439 2 pps Super CBL Mud Program: Production Mud Properties: 18.5" hole section: LSND Depth Density Marsh Yield 10 sec LSRV pH Fluid CI- (PPG) Viscosity Point 10 Min YP Loss Gel Milling 9.5-10 65-95 30-40 8-16 8.5- <6 11 - 24 9.5 Intermediate 9.5-10 40-55 10-18 4-10 4-9 9-9.5 <6 30k- 40k Reservoir 10 - 10.4 48 - 62 26 - 48 45k - 55k 8.5 - <6 35k - 9.0 45k Hazards/Concerns Pore pressure (_+8 - 9.4 ppg EMW) based on offset SIBHP. Lost Circulation due to overbalance in Flow sands. Differential sticking with overbalance situation. Excessive Torque to be combated with lubricant additions after testing. Directional: KOP' Maximum Hole An~lle: Tangent Angle Close Approach Well: 93O8' MD 46.54° .0-° Well 4-40/P-43 is 1265 feet at 10,609 feet. Drilling Hazards DRILLING CLOSE APPROACH WELL SHUT-INS There are no drilling close approach wells after the sidetrack of the original 4-44a/M-40 wellbore other than well 4- 40/P-43. This well is 1265 feet away (wellbore to wellbore), and is minimum risk of collision. PORE PRESSURE /LOST CIRCULATION Production Interval (8.5"): The Kekiktuk Sands reservoir pressure may be slightly higher than normal AND VARIES GREATLY, but the Asset pore pressure (based on nearby 3B BHP of 4180 - 4890 psi at 10,000' TVDss) should range from _+ 8.0 to 9.4 ppg EMW. The formation also has the potential for lost circulation (see Geologic Prognosis for faulting details). Lubricant additions (see above) should be utilized if torque and drag become troublesome, and after extensive testing of mud on location. Flex collars should be utilized in the BHA to minimize potential differential sticking. Liquid casing and OM seal should be on location to help combat severe lost circulation. NOTE: See the Geologic locations and sizes. UPI history. Prognosis for a detailed description of the expected fault Review the Pad Data Sheet for trouble highlights throughout Well Control: Well control equipment consisting of 5,000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Disposal Cuttings Handling: CC2A Fluid Handling: Annular injection is not available at Endicott for this well. 4-44a/M-40a Drilling Permit 3/10/97 General Orilling Discussion The 4-44a/M-40 well on MPI at Endicott will target the Kekiktuk in the MPI 3A3 in accordance with the 1996 development plan. We will have to abandon the existing perforation in the 4- 44a/M-40 well, by pulling a plug in the lower completion, pumping cement down coil tubing, cut production tubing, circulate KWM, pull tubing with the rig, set a whipstock, cut a window, and kick off through the 9-5/8" casing to the new M-40 BHL utilizing the 7" liner design. We will not pull the existing production packer or tailpipe in this well. The liner length will be _+ 4138 feet, with the top of the liner hanger back into the 9-5/8" casing. There have been problems with sidetrack wells especially keeping the metal cuttings from sticking the BHA. The milling fluid is designed to clean the hole if flow rates are kept high and the ditch magnets are closely monitored for recovery. A standard 6 valve slimhole (4.5" x 1" for 7" casing) GLM design will be run for the completion on a 4.5" L-80 tubing design with a X/X/XN nipple profile. Directional Plan: The directional plan for the 4-44a/M-40 well consists of kicking off via whipstock and conventional BHA's for the Kekiktuk Flow sands. Current plans call for 8°/100' doglegs below the whipstock, but this may be adjusted pending results during the drilling process. After sidetracking off the whipstock and steering directionally back into the Sands with 43° of inclination, the well will be drilled to_+13,289' MD (10,436' TVD). THE DIRECTIONAL TARGET CAN BE INTERSECTED ANYWHERE WITHIN THE TARGET BOUNDRY. THUS UNNECESSARY AND VERY EXPENSIVE SLIDING SHOULD BE AVOIDED TO KEEP THE WELL EXACTLY ON THE WELLPATH. THERE IS NOT ANY GEOSTEERING APPLICATION FOR THIS WELL. Ensure that any and all tolerance lines are not crossed to avoid policy violations. Please coordinate this through both the Operations Drilling Engineer and the Endicott Drilling Superintendent. There are not any known close approaches which require wells be shut in. Any BHA's indicating less than required BUR should immediately be pulled for a more aggressive assembly, Recommended BHA's All motors should be jetted properly to account for the proposed flowrates. Hole conditions and directional objectives should dictate actual flowrates. As mentioned previously, flex collars should be utilized in the 8.5" hole sections to minimize potential differential sticking. We will be using bent housing motors with either 7/8 or 5/6 rotor/stator configurations. Sperry proposed BHA's are attached, however the actual BHA with motor design, MWD/LWD tool configuration, MWD battery life, bit hydraulics should be discussed at the daily wellsite meeting. Survey Program The survey program for 4-44a/M-40 calls for use of Sperry's DWD MWD surveys the entire well. Because of Sperry's standard practice of changing the MWD probes after every bit run, an electronic single shot (ESS) will not be needed, and a gyro is not warranted. Close attention to JORPS is required, with the use of checkshots and survey data validation. Bit Program We will kick off the in the Seabee Shale with a conventional directional BHA and roller cone bit, which should make it to the Kekiktuk. After milling off the whipstock window, a 8.5" tangent section is planned to the Kekiktuk. The penetration rate will vary due to the variable lithology, but these bits have proven durable enough to drill through most of this interval. However, if there is any indication of bit failure such as torque spikes, the bit should be pulled at the descretion of the rigsite team. It remains the Endicott Doyon 15 wellsite TEAM's resposibility to confirm these bits are the best choice before running based on actual drilling conditions and bit performance. 4-44a/M-40a Drilling Permit !~/~ ~. ~, ~.-,,-,-~:~ 3/10/97 We have had a problem with b'rr"grading on recent wells when the bits grade change after they are returned to town, indicating we could have run more aggressive bits. It is recommended that the bit company, toolpusher, directional driller, company representative jointly grade bits before they are entered on the DEAP report. Recommended Jet Sizes Expected Interval Bit Type Flowrate HSI Whipstock and Standard Window Mills 500 - 550 gpm window 8.5" Kickoff -Tangent ATJ-03 - ATJ-09 550 - 600 gpm 3 x 12 2.9 - 4.8 8.5" Reservoir ATJ-P18HD 550 - 600 gpm 3 x 15 2.9 - 4.8 NOTE: Real time rigsite information such as condition of bits previously pulled, hole conditions, drilling fluids, downhole motor constraints (if any) will be instrumental in actual final bit selection. PDC bits will be run in the 8.5" hole section only if Sperry 6-3/4" performance motors are available, and ONLY WHERE ECONOMICAL. Mud Program: Because of the problems with Sheardril, we will use LSND on this well. The problems of lubricant additions in a (high weight - high calcium carbonate - high chloride) system severely hampered the drilling process on the both SDI wells Sheardrill was used on. There should not be any additions of any lubricants in this well without extensive testing of the actual fluid on location. A new Gel/Biozan polymer will be used for milling the window. Ditch Magnets should be used and WEIGHED to ensure metal cuttings removal. Rheology control can be maintained using Gel and Biozan polymer. A lower YP should be sufficient until the start of the kick off. At this time raise the LSR YP to the recommended range using Biozan. Biozan sweeps should be pumped to assist in hole cleaning and to prevent the build up of cuttings beds. Additions of Baranex should begin around 10500 MD and should result in an HPHT of <15 which is our target. Maintain the pH in the 9-9.5 range using caustic soda. Additions of 3#/BBL each of Baranex and Barotrol should begin around 8500~ TVD.This treatment should be maintained to the end of this interval. This treatment should result in an HPHT of <14 which is our target. Maintain the pH in the 9-9.5 range using caustic soda. If torque problems arise, a treatment of 1- 2% Lubetex should be used. If the torque persists, the additions should be increased to 3% Lubetex. The LSND mud will be taken to TD on this well. Maintain the weight at the density required in the intermediate section. The Barotrol and Baranex treatments should be maintained at 3#/bbl. The APl filtrate should be reduced to the 4 cc range with PAC and starch. This will reduce the chances of differential sticking and reduce filtration invasion. Tripping Practices / Stuck Pipe / Hole Cleaning Tripping in the 8.5" hole interval should be undertaken with caution due to swabbing possibilities with high viscosity fluids. The bottom hole pressure varies from 4180 psi to 4890 psi (8 to 9.4 ppg ). It is recommended that mud weights be maintained in the 9.5 to 10 ppg range to control the hydrocarbon intervals, maintain shale stability and minimize the possibility of differential sticking. Faulted intervals may require additions of LCM prior to tripping to insure that the hole remains full at all times. Keep the pipe moving and have an ample supply of lost circulation materials on hand. Baroid recommends utilization of Iow viscosity sweeps to assist with hole cleaning and to minimize the formation of cuttings beds on the Iow side of the hole. No potential hazardous levels of H2S are anticipated in the 4-44a/M-40 well. There been H2S reading on offset MPI wells of over 1000 ppm. Ensure rig detectors are calibrated prior to N/D tree and/or circulating to kill the well. have gas Logging Program: I Logs: 18.5" Hole Tan~lent and Curve I 8.5" Hole Reservoir I Wireline Lo~ls - TD to HRZ I Cased Hole: MWD MWD GR only DIL/LDT/CNL/GR, RFT Based on OH Logs No The following summarizes logging evaluation needs: 4-44a/M-40a Drilling Permit 3/10/97 MWD MWD will not be run as we can use wireline tools to TD. Wireline Wireline logs are planned to provide enhanced formation evaluation of this fault block. Sample catchers and a wellsite Geologist are planned to be used while drilling reservoir. Casing and Cementing This sidetrack well will require a single 7" 29# L-80 liner to be run across the entire interval. This will be hung off in the 9-5/8" casing at 9100 feet. Make sure we have 5000 feet of 5" "S" drill pipe to allow fo the maximum overpull. Ensure that prior to running liner that the hole is in good condition and that the mud has been conditioned to run casing. Before POll to run liner spot lubricant across the open hole section. If this is considered essential to getting the pipe to bottom ensure that adequate lubricant testing has been performed prior to doing this. Also, consideration must be given to a hole opener trip prior to running liner if hole conditions suggest that there may be problems running pipe. The liner should be filled every 5 joints, and circulated prior to going into open hole. Any problem intervals identified while drilling, such as ledges in the Tuffs, will require special care while running casing through. The liner will require 2 straight blade centralizers on every joint to the 200 feet above the top of the Kekituk at _+ 12,849'. If the liner starts to packoff in the open hole, establish circulation and try to wash through. Do not continue to run casing without circulation. If necessary, we will pull casing and make a wiper trip prior to running the liner. The liner running procedure in the detail section should be reviewed. The cementing program is designed place cement 1000 feet above the top of the Kekiktuk formation. The approximate volume will be 300 sacks of Class 'G' with additives as speficied in the casing detail section. Cementing operations at Endicott are continue to be critical with the advancement of both the waterflood and gas fronts. Close attention to detail for this part of the well is critical for the economical success of our drilling program. Through Tubing Conveyed Perforating This well will require TTCP perforating after running the completion across the pay as identified by MWD and Wireline logs. It is therefore critical these FINAL Field Prints logs are sent to town after a QA/QC procedure insures the data is adequate to pick the perforated interval. 4-44a/M-40a Drilling Permit 3/10/97 SUMMARY COMMENTS PROCEDURE 1. The 9-5/8" x 4-1/2" production packer is a Baker permanent packer with a tubing seal assembly above, and will not be recovered. There is a plug in the WD Packer. 2. The new 7"x 4.5" packer should be set at +/- 12,700' MD. PRE-RIG OPERATIONS 1. RU wireline, Pull the WL SSSV. Drift and dummy off gas lift mandrels. 2. Call and notify AOGCC. 3. Pump 75 sx of class G cement and cimulate down the coil tubing. Displace to 13,963' MD. Pull coil above cement to 12,863 and squeeze cement into perforations up to 1500 psi. Pull coil from well. RU wireline and cut tubing above X nipple at 13,649' MD with chemical cutter. Circulate the 4.5" tubing with 1.5 volumes of 9.5 ppg brine or milling fluid. Check.that the well is dead. Freeze protect the top 200' with diesel. Set BPV. Note: Maintain contact with Drilling. If rig move is delayed to more than four days after the well kill, a deeper freeze protect will need to be done by the PE's. Dig out the cellar and level the pad. Inspect the wellhead and tree. Replace the 9-5/8" packoff and function test the LDS's. OPERATIONS (SUMMARY) 1. Mobilize Doyon 15. Review Endicott Simultaneous Operations Plan concerning rig moves. Check that the well is dead. If not circ well w/brine or milling fluid until the well is dead. ND the tree, and NU the BOPE. Test the BOPE and pull BPV. (1/2 day) Screw into the landing joint. Pull and LD the tubing. (1 day) Run and set 9-5/8" wireline bridge plug at 9,323 MD with CCL to set BP 3 feet below collar. (1/2 day). P/U 9-5/8" whipstock and milling BHA and TIH to cut window from 9,293 - 9,308' MD. (2 days) POOH w/mills. (1/2 day) Pick up Sperry 6.75" directional BHA to turn and drop @ 8°/100 feet to 0° at appx 9889' MD. Drill ahead as specified by the rigsite geologist to TD at 13,288'MD. POOH. (15 days) If hole conditions dictate, run HO over hole interval and spot lubricant in OH section. POOH. Run 7" solid liner from 9,100' to 13,288' MD, reciprocate for as long as possible and cement as per plan. (2 days) RIH w/7" x 4-1/2" packer, 4-1/2" L-80 tubing, and 6 GLM to expected setting depth at 12,700 MD. Drift packer, tubing and all jewlery before running. (1 day) Pump Corrosion inhibitor. Set the 7" packer. Test the tubing to 3500 psi. Test the packer and IA to 3500 psi. (1/2 day) 13. Set the BPV. ND the BOPE, and NU the tree. Shear the RP valve and freeze protect the well. (1/2 day). 14. Turn the well over to Production. 15. Perforate with TTCP charges at 1000 psi underbalanced with perforation intervals picked from logs. (3days) . . . RIG . . . . . . . 11. 12. 4-44a/M-40a Drilling Permit 3/10/97 Sha d Services DrillingI Structure SOl Well: 4-44A/M-40 Field · Endicott Location: Alaska 6500 - -- 6600 - -- 6900 - - 7200 - 7500 - 7800 - 81 O0 - -- 84-00 - 8700 - - 9000 - - 9300 - _ 9900 - 10200 - 10500 - 10800 - 11100 5000 WELL PROFILE DATA Point MD Ino Dir TVD North Tie on 9508 46.54 96.29 6741 -5.38 Tie on End of Drop 9890 0 O0 92,30 7261 -562 40,00 ' ' 32.00 KOP 12105 0.00 92.30 9476 -562 4.00 End of Build 12~26 41.64 57.89 9952 -419 I ~® :nd of Hold 12626 41.64 57.89 9952 --419 M-40 Wp8 ~'"Z,'g'/~,e';"'~'~.l, Tdrge[2/TD/7' Liner: 1,~289 MD ~ East DLg(deg/lOOft) 5538 0.00 5760 8.00 5760 0.00 5872 8.00 5872 0.00 5905 8.00 6196 0.00 I I I I I I I I I I I I I I I I I I I I I I I I I I 3.'300 3600 3900 4200 4500 4800 5100 5400 5700 6000 6300 6600 6900 S c o I e 1 ' $ 00. 0 0 v,~t,~o, Sectl .... 48.75 azimuth with ret ...... 0.00 N, 0.00 W from 4-44A/bi-40 Shared Services Drilling Structure: End SDI Well' 4-44A/M-40 Fie d: Endicott Location · Aldskd Scale 1 ' 100.00 I 4-44A/M-40 Wp8I 5000 5100 5200 5300 5400 5500 5600 5700 5800 5900 6000 6100 6200 6300 6400 6500 6600 200 100 - -I00- ~ -300- ·] , - O -400- _ -500- o -60O- d - · · -700- -- ~ -800 TARGET DATA MD Inc Dir TVD North East -- Name .... Position -- 13289 45,19 46.27 10436 -104 6196 Target 2 27661 0, 5970530 12699 43,19 46.27 10006 -383 5905 Target I 276310, 5970260 N TRUE NORTH ~00 9750 7000 7" L~er )o Target 1 10250 725O Target 2 7500 775O 2OO - 100 - 0 --100 -- 3oo - ----400 --500 --600 -- --700 -- -800 5000 5100 5200 5500 5400 5500 5600 5700 5800 5900 6000 6100 6200 6500 6400 6500 6600 Scale 1 ' 100.00 East = > 4-44A/M-40 Wp8 (9308 KOP with New Geology and 10436TVDrkb TD) Vertical Section 48.75° RKB 56.00' MD Inc. Azi. TVDss TVDrkb Rect. Coordinates Grid Coordinates Northing Easting Easting 9308.00 46.54 96.29 6684.79 6740.79 537.70s 5538.18e 275939.01 9400.00 39.18 96.29 6752.19 6808.19 544.55s 5600.33e 276000.92 9500.00 31.18 96.29 6833.86 6889.86 550.86s 5657.55e 276057.92 9600.00 23.18 96.29 6922.75 6978.75 555.87s 5702.91e 276103.11 9700.00 15.18 96.29 7017.12 7073.12 559.47s 5735.53e 276135.60 9800.00 7.18 96.29 7115.15 7171.15 561.59s 5754.78e 276154.78 9889.69 0.00 92.30 7204.60 7260.60 562.20s 5760.36e 276160.33 9900.00 0.00 92.30 7214.91 7270.91 562.20s 5760.36e 276160.33 10000.00 0.00 92.30 7314.91 7370.91 562.20s 5760.36e 276160.34 10100.00 0.00 92.30 7414.91 7470.91 562.20s 5760.36e 276160.34 10200.00 0.00 92.30 7514.91 7570.91 562.20s 5760.37e 276160.34 10300.00 0.00 92.30 7614.91 7670.91 562.20s 5760.37e 276160.34 10400.00 0.00 92.30 7714.91 7770.91 562.20s 5760.37e 276160.34 10500.00 0.00 92.30 7814.91 7870.91 562.20s 5760.37e 276160.35 10600.00 0.00 92.30 7914.91 7970.91 562.20s 5760.37e 276160.35 10700.00 0.00 92.30 8014.91 8070.91 562.20s 5760.38e 276160.35 10800.00 0.00 92.30 8114.91 8170.91 562.20s 5760.38e 276160.35 10900.00 0.00 92.30 8214.91 8270.91 562.20s 5760.38e 276160.35 11000.00 0.00 92.30 8314.91 8370.91 562.20s 5760.38e 276160.35 11100.00 0.00 92.30 8414.91 8470.91 562.20s 5760.38e 276160.36 11200.00 0.00 92.30 8514.91 8570.91 562.20s 5760.38e 276160.36 11300.00 0.00 92.30 8614.91 8670.91 562.20s 5760.39e 276160.36 11400.00 0.00 92.30 8714.91 8770.91 562.21 s 5760.39e 276160.36 11500.00 0.00 92.30 8814.91 8870.91 562.21 s 5760.39e 276160.36 11600.00 0.00 92.30 8914.91 8970.91 562.21s 5760.39e 276160.36 11700.00 0.00 92.30 9014.91 9070.91 562.21 s 5760.39e 276160.37 11800.00 0.00 92.30 9114.91 9170.91 562.21 s 5760.39e 276160.37 11900.00 0.00 92.30 9214.91 9270.91 562.21 s 5760.40e 276160.37 11915.09 0.00 92.30 9230.00 9286.00 562.21 s 5760.40e 276160.37 12000.00 0.00 92.30 9314.91 9370.91 562.21 s 5760.40e 276160.37 12100.00 0.00 92.30 9414.91 9470.91 562.21 s 5760.40e 276160.37 12105.03 0.00 92.30 9419.94 9475.94 562.21 s 5760.40e 276160.37 12200.00 7.60 37.89 9514.63 9570.63 557.24s 5764.26e 276164.38 12300.00 15.60 37.89 9612.51 9668.51 541.39s 5776.60e 276177.20 12354.08 19.92 37.89 9664.00 9720.00 528.37s 5786.73e 276187.71 12400.00 23.60 37.89 9706.64 9762.64 514.94s 5797.18e 276198.57 12500.00 31.60 37.89 9795.19 9851.1 9 478.41s 5825.61 e 276228.09 12600.00 39.60 37.89 9876.44 9932.44 432.50s 5861.32e 276265.18 12625.58 41.64 37.89 9895.85 9951.85 419.36s 5871.55e 276275.80 No~hing 5970116.27 5970107.54 5970099.49 5970093.11 5970088.53 5970085.82 5970085.04 5970085.04 5970085.04 5970085.04 5970085.04 5970085.04 5970085.04 5970085.04 5970085.04 5970085.04 597OO85.O4 5970085.04 5970085.04 5970085.04 5970085.04 5970085.04 597OO85.O4 5970085.04 5970085.04 5970085.04 5970085.04 5970085.04 5970085.04 5970085.04 5970085.04 5970085.04 5970089,88 5970105.35 5970118.05 5970131.16 5970166.81 5970211.61 5970224.43 DLS deg/100ft 0.00 8.00 8.00 8.00 8.00 8.00 8.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 8.00 8,00 8.00 8.00 8.00 8.00 8.00 Vertical Section 3809.30- 3851.51 3890.36 3921.17 3943.32 3956.39 3960.18~' 3960.18 3960.18 3960.18 3960.19 3960.19 3960.19 3960.19 3960.19 3960.19 3960.19 3960.19 3960.20 3960.20 3960.20 3960.20 3960.20 3960.20 3960.20 3960.20 3960.21 3960.21 3960.21 3960.21 3960.21 3960.21 3966.39 3986.11 4002.31 4019.03 4064.49 4121.61 4137.96 Comment Top Tuffs: 11915 MD Top HRZ: 12354 MD 3/5/97 1:42 PM Page 1 of 2 4-44A/M-40 Wp8 (9308 KOP with New Geology and 10436TVDrkb TD) Vertical Section 48.75° RKB 56.00' MD Inc. Azi. TVDss TVDrkb Rect. Coordinates Grid Coordinates Northing Easting Easting 12625.59 41.64 37.89 9895.86 9951.86 419.35s 5871.55e 276275.81 12655.34 42.20 41.35 9918.00 9974.00 404.05s 5884.23e 276288.94 12698.87 43.19 46.27 9950.00 10006.00 382.77s 5904.65e 276310.00 12767.45 43.19 46.27 10000.00 10056.00 350.33s 5938.57e 276344.89 12781.01 43.19 46.27 10009.89 10065.89 343.91s 5945.28e 276351.78 12842.88 43.19 46.27 10055.00 10111.00 314.64s 5975.88e 276383.26 12881.01 43.19 46.27 10082.80 10138.80 296.61s 5994.74e 276402.65 12981.01 43.19 46.27 10155.71 10211.71 249.30s 6044.20e 276453.52 13081.01 43.19 46.27 10228.62 10284.62 201.99s 6093.66e 276504.39 13181.01 43.19 46.27 10301.53 10357.53 154.69s 6143.11e 276555.26 13281.01 43.19 46.27 10374.44 10430.44 107.38s 6192.57e 276606.12 13288.62 43.19 46.27 10380.00 10436.00 103.78s 6196.34e 276610.00 Northing 5970224.44 5970239.35 5970260.00 5970291.40 5970297.61 5970325.94 5970343.39 5970389.17 5970434.95 5970480.73 5970526.51 5970530.00 DLS deg/100ft 0.00 8.00 8.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Vertical Section 4137.97 4157.59 4186.98 4233.87 4243.14 4285.45 4311.52 4379.89 4448.27 4516.64 4585.02 4590.23 Comment Base HRZ: 12655 MD TFU 4/Target 1:12699 MD TFU 3: 12767 MD TFU 2: 12843 MD Target 2/TD/7" Liner: 13289 MD 3/5/97 1:42 PM Page 2 of 2 TREE: 6-3/8" / 5000 P'~MCEVOY/OTIS (SSV) R.T. ELEV = 56' ~'-" ~ ClW/AXELSON (WING) B.F. ELEV =, ' WELLHEAD:. 13-5/8"/5000 psi / FMC MAX DEV =62.31° @ 5,40O' MD. ' (4.562" I. B) 13-3/8", 68#/ft, ~80CYHE, Btm Csg ~ ~ 5-1/2", 17~/lt, b80, 0-5/8", 47~/~t ~1808 ~C XO (5-1/2" MfiB~ W/1-1/2" BK tO NTO5HS N~C I~ ~ NO. MDB~ ,~ , ~ ¢2 4,572' 3,830' 11 876' ~ . ' ¢ 1 13,629' 9,674' 9-5/8", 47~/ft ~95HS N~C XO to ~95HS LT&C l.I I ~o~ o~ 7,, u~[~ i,,,,,, I' I 0-5/8", 47~/~t, ~I05HS PER~RA~NO SUMMARY Ref. ~.g: ~4/8/92 CO. GUN ~F I~ERVAL ~.S 4-1/2" 5 14,0,63 - 14,1Q0 14,294- 14,315 , 14,45,8- 14,50,0 10,000' ~G~= 14,026' MD FI~ IN "WD' PACKER ARE ~P ~GME~S WHICH FE~ 7" OTIS "WD' PKR I~O PACER BORE. W/4-1/2 .... X" NIPP~ PACER HAS ~D ~WNHO~ (3.813" I.D.) FROM ORGINAL~T & 4-1/2 .... XN" NIPP~ POSITION., , ~ ~ (3.725" I.~.) ~ 4-~/2" Dine By Commems , ENDICOTTwELL: 4-44/Mx44 ', 6/5/92 u~ mA~ COPY APl NO. 50-029~22254 ~ COMPLETION DIAGRAM 6/9/92 J~ COM P~TION , ~.~,~ ~~O~ATION (ALASKA), INC I I SDI WELL 4-44/M-40(WP3) SURFACE & DOWNHOLE LOCATIONS 2/27/97 ~ NAME COIV~ENTS ALASKA STATE PLAN E ZONE 3 (NAD 27) DECIMAL DEGREES (NAD 27) S & E SEC MNE OFFSETS SECTION, TOWN., NEAREST SECTION MNE OFFSETS NO. Y X LATITUDE (N°) LONGITUDE (W~) FSL FEi. RANGE, UMIAT, AK DIST. MNE DIST. LINE I SDI 4-44/M-40 Surface Surface Location 5,970,821.49' 270,420.25' 70.3219174° 147.8615750° 2609 618 SEC 08 T11N R17E 2609 S 618 E 2 SDI 4-44/M-40 Start Dir @ 8/100 Plan Downhole Loc. 5,970,116.27' 275,939.01' 70.3204473° 147.8166835° 2071 361 SEC09 T11N R17E 2071 S 361 E 3 SDI 4-44/M-40 Base HRZ/Top Kukiktuk: 12851 Plan Downhole Loc. 5,970,202.65' 276,257.76' 70.3207092° 147.8141216° 45 2167 SEC 09 T11N R17E 2167 S 45 E 4 SDI 4-44/M-40 TD/7" Liner:13316 MD Plan Downhole Loc. 5,970,542.56' 276,623.95' 70.3216672° 147.8112363° 2517 4968 SEC 10 T11N R17E 2517 S 312 W __ Notes: Coordinates shown are North American Datum 1~27 (NAD 27). F. Robert Bell & Assoc. Jeff Cotton 564-4969 File Name: SDIBH.XLS 2/27/97 NW Sec 8 T11N R17E Umiat X=265834.320 Y=5973635.570 SWSec8 T11N:R17E Umiat X=265688.100 Y=5968357.700 528O 91o46'07" 4-44/M-40 "4-44" SURFACE LOCATION X=270420.250 Y=5970821.490 528O 271o46,06'' N Sec 8&9 T11N R17E Umiat X=271111.600 Y=5973472.630 618 S Sec 8&9 T11N R17E Umiat X=270965.390 Y=5968194.780 SDI Well Downhole 2/27/97 4-44/M-40 Location Section Line Ties 528O 91o43'42" N Sec 9&10 T11N R17E Umiat X=276388.970 Y=5973313.400 4-44/M-40 Base HRZ/Top Kekikuk X=276257.760 Y=5970202.650 4-44/M-40 Start Dir @ 8/100 X=275939.010 Y=5970116.270 528O 271o43'4O'' 45 361 "r"- 312 . S Sec 9&10 T11N R17E Umiat X=276242.770 Y=5968035.580 528O 91o41'16" NE Sec 10 T11N R17E Umiat X=281666.470 Y=5973157.890 4-44/M-40 TD/7"Liner:13316MD X=276623.950 ¥=5970542.560 528O 271o41,16'' SE Sec 10 T11N R17E Umiat X=281520.220 Y=5967880.080 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Vadance [] Other [] Change Approve, d Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2671' SNL, 618' WEL, SEC. 8, T11N, R17E At top of productive interval 3861' SNL, 2367' WEL, SEC. 10, T11N, R17E At effective depth 3949' SNL, 2074' WEL, SEC. 10, T11N, R17E At total depth 3960' SNL, 2034' WEL, SEC. 10, TllN, R17E 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) KBE = 56' 7. Unit or Property Name Duck Island Unit/Endicott 8. Well Number 4-44/M-44 9. Permit Number 92-19 10. APl Number 50-029-22254 11. Field and Pool Endicott Field / Endicott Pool 12. Present well condition summary Total depth: measured 14691 feet true vertical 10621 BKB feet Effective depth: measured 14610 feet true vertical 10552 BKB feet Casing Length Structural Conductor 92' Surface 2362' Intermediate 13953' Production Liner 938' Plugs (measured) Junk (measured) 14355' 7" WD Pkr W/X and XN nipples at 14554' Size Cemented 30" Driven 13-3/8" 1554 c.f. Permafrost 9-5/8" 3155 c.f. Permafrost 7" 450 c.f. Class 'G' MD TVD BKB BKB 131' 131' 2401' 2352' 13992' 10028' 13753'-14691' 9774'-10565' Perforation depth: measured true vertical 14063'-14100', 14294'-14315', 14458'-14500' (subsea) 10087'-10118', 10282'-10300', 10420'-10456' Tubing (size, grade, and measured depth) 5-1/2" 17# L-80 tubing with 4-1/2" 12.6# L-80 tailpipe to 13809' Packers and SSSV (type and measured depth) 13. Attachments [] Description summary of proposal 9-5/8" packer at 13698'; 5-1/2" SSSV at 1596' [] Detailed operations program [] BOP sketch 14. Estimated date for commencing operation April 1, 1997 16. If proposal was verbally approved Blair Wondzell Name of approver 02/21/97 Date approved 15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Water Injection Contact Engineer Name/Number: Chris West, 564-5089 ¢.~ Prepared By Name/Number: Kathy Campoamor, 564-5122 17. I hereby certify that the foregoing is t[ue apd correct to the best of my knowledge Signed I ,'-~,,.~ ~.~ SteveShultz -~.- -- _ Title Senior Drilling Engineer " Commission Use Only C o n dj~ ~r~ ~f/e'~ ~8~a I: Notify Commission so representative may witness I Approval · -~;" Plug integrity ""'"--- BOP Test ~ Location clearance ,. - Returned -- -~ [~L JC~ 3__ Mechanical Integrity Test __ Subsequent form required 10- "~'~ Signed By Approved by order of the Commission ' " ~,~.~,~nn Commissioner Date Form 10-403 Rev. 06/15/88 :~;id W uu~.~,~ ' ' teSubmiLIn [riplica WELL PERMIT CHECKLIST o. FIELD & POOL ADMINISTRATION ENGINEERING 7. 8. 9. 10. 11. ° 12. 13. : expD dev D redrl~.serv~ wellbore seg~ ann disp para reqD Cuss /_ ? GEOL IT, O./OFF O 1. Permit fee attached .................. 2. Lease number appropriate ............... 3. Unique well name and number .............. 4. Well located in a defined pool ............. 5. Well located proper distance from drlg unit boundary.. 6. Well located proper distance from other wells ..... Sufficient acreage available in drilling unit ..... If deviated, is wellbore plat included ........ Operator only affected party .............. Operator has appropriate bond in force ......... Permit can be issued without conservation order .... Permit can be issued without administrative approval.. Can permit be approved before 15-day wait.' ...... REMARKS N N N N N N N N N N N N N 14. Conductor string provided ................ Y Nh 15. Surface casing protects all known USDWs ......... Y N 16. CMT vol adequate to circulate on conductor & surf csg.. Y N 17. CMT vol adequate to tie-in long string to surf csg . ..~ N 18. CMT will cover all kno~ productive horizons ...... .N I9. Casing designs adequate for C, T, B & permafrost .... N 20. Adequate tankage or rese~e pit ............. ~ N ~./~~ 21. If a re-drill, has a 10-403 for abndnmnt been approved..Y N ;~ 22. Adequate well,ore separation proposed .......... ~ N 23. If diverter required, is it adequate .......... ~---'~~ schematic & equip list adequate ~ N 24. Drilling fluid program 25. BOPEs adequate ............ ~-~_~~ ........ Pv')~. N 26. BOPE press rating adequate; test to~___~_~?______psig.~ N 27. Choke manifold complies w/~I ~-53 (May)-~ ...... ~ ~ ~ ~ 28. Work will occur withou~ operation shutdo~ ....... ~ N 29. Is presence of H2S gas probable ............ Y~/ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... 32. Seismic analysis of shallow gas zones ......... 33. Seabed condition survey (if off-shore) ....... /. Y N -- ' 34. Contact name/phone for weekly progress reports ..... Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: HOW/dlf- A:\FORMS~heklist rev 01197